Star macromolecules for wellbore applications

ABSTRACT

The present disclosure provides treatment fluids that comprise star macromolecules as a fluid loss additive or a viscosifier. An embodiment of the present disclosure is a method comprising: providing a treatment fluid that comprises: an aqueous base fluid; and a star macromolecule that comprises: a hydraulic polymeric core, a first group of polymeric arms attached to the core wherein each of the arms in the first group consists of hydrophilic monomers, and a second group of polymeric arms attached to the core wherein each of the arms in the second group comprises at least one hydrophilic homopolymeric segment and at least one hydrophobic homopolymeric segment; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

CROSS-REFERENCE TO RELATED APPLICATION

The present application is a U.S. National Stage Application ofInternational Application No. PCT/US2015/050185 filed Sep. 15, 2015,which is incorporated herein by reference in its entirety for allpurposes.

BACKGROUND

The present disclosure relates to systems and methods for treatingsubterranean formations.

Natural resources such as oil or gas residing in a subterraneanformation can be recovered by drilling a wellbore that penetrates theformation. The wellbore passes through a variety of subterraneanformations. This may include non-reservoir zones (i.e., formations thatdo not contain oil and gas) and reservoir zones (i.e., formations thatdo contain oil or gas). The subterranean formations may also havevarying degrees of permeability. During the drilling of the wellbore, adrilling fluid may be used to, among other things, cool the drill bit,lubricate the rotating drill string to prevent it from sticking to thewalls of the wellbore, prevent blowouts by serving as a hydrostatic headto the entrance into the wellbore of formation fluids, and remove drillcuttings from the wellbore. A drilling fluid may be circulateddownwardly through a drill pipe and drill bit and then upwardly throughthe wellbore to the surface.

When the drilling fluid contacts permeable subterranean formations,fluid (e.g., water or oil) may be lost into the formation. A drillingoperation where this has occurs may also be said to have “fluid loss.”Fluid loss control additives may be included in the drilling fluid toreduce fluid loss into the formation. Fluid loss and lost circulationcan be more significant during drilling operations intohigh-permeability zones (e.g., unconsolidated zones or depletedformations), vugular zones, and fractures (e.g., either pre-existingfractures or fractures created during the subterranean operation). Whenthe permeability of the formation is high, for example, because ofunconsolidated formations or microfractures, the rate of fluid loss mayincrease to the point where the drilling fluid can no longer becirculated back to the surface as efficiently, or at all.

BRIEF DESCRIPTION OF THE DRAWINGS

These drawings illustrate certain aspects of some of the embodiments ofthe present disclosure, and should not be used to limit or define theclaims.

FIG. 1 is a diagram illustrating an example of a star macromolecule thatmay be used according to certain embodiments of the present disclosure.

FIG. 2 is a diagram illustrating an example of a star macromolecule thatmay be used according to other embodiments of the present disclosure.

FIG. 3 is a diagram illustrating an example of a system where certainembodiments of the present disclosure may be used.

While embodiments of this disclosure have been depicted, suchembodiments do not imply a limitation on the disclosure, and no suchlimitation should be inferred. The subject matter disclosed is capableof considerable modification, alteration, and equivalents in form andfunction, as will occur to those skilled in the pertinent art and havingthe benefit of this disclosure. The depicted and described embodimentsof this disclosure are examples only, and not exhaustive of the scope ofthe disclosure.

DESCRIPTION OF CERTAIN EMBODIMENTS

The present disclosure provides compositions and methods for fluid lossadditives and viscosifiers. More particularly, in certain embodiments,the present disclosure relates to treatment fluids that comprise starmacromolecules as a fluid loss additive or a viscosifier.

The present disclosure provides star macromolecules as fluid lossadditives or viscosifiers that may be tailored for various treatmentfluids. In accordance with embodiments of the present disclosure, atreatment fluid may comprise a base fluid and a fluid loss additivecomprising a star macromolecule. In accordance with other embodiments ofthe present disclosure, a treatment fluid may comprise a base fluid anda viscosifier comprising a star macromolecule. In either embodiment, thetreatment fluid may comprise additional components including, but notlimited to, additional viscosifiers, pH controlling agents, defoamers,weighting agents, bridging agents, lubricants, corrosion inhibitors,thinner, shale stabilizers, oxygen scavengers, H₂S scavengers, andemulsifiers.

The treatment fluids used in the methods and systems of the presentdisclosure may comprise any base fluid known in the art, includingaqueous base fluids, non-aqueous base fluids, and any combinationsthereof. The term “base fluid” refers to the major component of thefluid (as opposed to components dissolved and/or suspended therein), anddoes not indicate any particular condition or property of that fluidssuch as its mass, amount, pH, etc. Aqueous fluids that may be suitablefor use in the methods and systems of the present disclosure maycomprise water from any source. Such aqueous fluids may comprise freshwater, salt water (e.g., water containing one or more salts dissolvedtherein), brine (e.g., saturated salt water), seawater, or anycombination thereof. In some embodiments of the present disclosure, theaqueous fluids comprise one or more ionic species, such as those formedby salts dissolved in water. For example, seawater and/or produced watermay comprise a variety of divalent and monovalent cationic speciesdissolved therein. In certain embodiments, the density of the aqueousfluid can be adjusted, among other purposes, to provide additionalparticulate transport and suspension in the compositions of the presentdisclosure. In certain embodiments, the pH of the aqueous fluid may beadjusted (e.g., by a buffer or other pH adjusting agent) to a specificlevel, which may depend on, among other factors, acids, and otheradditives included in the fluid. One of ordinary skill in the art, withthe benefit of this disclosure, will recognize when such density and/orpH adjustments are appropriate. Examples of non-aqueous fluids that maybe suitable for use in the methods and systems of the present disclosureinclude, but are not limited to, oils, hydrocarbons, organic liquids,and the like. In certain embodiments, the treatment fluids may comprisea mixture of one or more fluids and/or gases, including but not limitedto emulsions, foams, and the like. Generally, the base fluid may bepresent in an amount sufficient to form a pumpable fluid. By way ofexample, the base fluid may be present in the treatment fluid in anamount in the range of from about 10% to about 99% by volume of thetreatment fluid. One of ordinary skill in the art with the benefit ofthis disclosure will recognize the appropriate amount of base fluid toinclude within the treatment fluids of the present invention in order toprovide a treatment fluid for a particular application.

The treatment fluids used in the methods and systems of the presentdisclosure may comprise one or more star macromolecules. As used herein,a “star macromolecule” refers to a molecule that comprises a polymercore and a plurality of polymer arms. In certain embodiments, the starmacromolecule comprises at least five polymer arms. The core and thearms comprise monomers that may be hydrophobic or hydrophilic dependingon the application. The core is a cross-linked polymer chain that may behydrophobic or hydrophilic depending on the application. The arms arepolymers that are attached to the core and comprise one or more polymeror copolymer segments. At least one arm or at least one segment/blockexhibits a different solubility from other arms.

In embodiments where the base fluid is a non-aqueous fluid, the starmacromolecule may comprise a cross-linked polymeric core that mayoptionally be hydrophobic. In this embodiment, hydrophobic arms and armswith both hydrophilic and hydrophobic segments are covalently attachedto the cross-linked hydrophobic core. FIG. 1 is one example of such astar macromolecule. Star macromolecule 10 includes a polymeric core 11.A plurality of hydrophobic arms 12 are attached to the polymeric core11. A plurality of arms 13 with both hydrophobic and hydrophilicsegments are also attached to the polymeric core 11. Each of arms 13includes a single hydrophobic homopolymeric segment 13 a attached to thepolymeric core 11 and a single hydrophilic homopolymeric segment 13 b ata distal end of the arm 13. The diagram of FIG. 1 can also berepresented by Formula 1:[(P1)_(k1)-(P2)_(k2)]_(m)-Core-[(P3)_(k3)]_(n)  Formula 1:

In these embodiments, P1 represents a hydrophilic homopolymeric segmentcomprised of repeating units of hydrophilic monomers. P2 represents ahydrophobic homopolymeric segment comprised of repeating units ofhydrophobic monomers. P3 represents a hydrophobic homopolymeric segmentcomprised of repeating units of hydrophobic monomers. k1 represents thenumber of repeating units in P1 and has a value between 1 and 50. k2represents the number of repeating units in P2 and has a value between10 and 500. k3 represents the number of repeating units in P3 and has avalue between 10 and 500. m and n represents the average number of armscovalently attached to the core.

In embodiments where the base fluid is an aqueous fluid, the structureis similar, but the hydrophobicity of the arms may be reversed. In theseembodiments, the star macromolecule may comprise a polymeric core thatmay optionally be hydrophilic. In this embodiment, hydrophilic arms andarms with both hydrophilic and hydrophobic segments are covalentlyattached to the cross-linked hydrophobic core. FIG. 2 is one example ofsuch a star macromolecule. Star macromolecule 20 includes a polymericcore 21. A plurality of hydrophilic arms 22 are attached to thepolymeric core 21. A plurality of arms 23 with both hydrophilic andhydrophobic segments are also attached to the polymeric core 21. Each ofarms 23 includes a single hydrophilic homopolymeric segment 23 aattached to the polymeric core 21 and a single hydrophobic homopolymericsegment 23 b at a distal end of the arm 23. The diagram of FIG. 2 canalso be represented by Formula 2:[(P1)_(k1)-(P2)_(k2)]_(m)-Core-[(P3)_(k3)]_(n)  Formula 2:

In these embodiments, P1 represents a hydrophobic homopolymeric segmentcomprised of repeating units of hydrophobic monomers. P2 represents ahydrophilic homopolymeric segment comprised of repeating units ofhydrophilic monomers. P3 represents a hydrophilic homopolymeric segmentcomprised of repeating units of hydrophilic monomers. k1 represents thenumber of repeating units in P1 and has a value between 1 and 50. k2represents the number of repeating units in P2 and has a value between10 and 500. k3 represents the number of repeating units in P3 and has avalue between 10 and 500. m and n represents the average number of armscovalently attached to the core.

In different embodiments, the core can be either hydrophobic orhydrophilic in both aqueous and non-aqueous base fluids. However, starmacromolecules with mainly hydrophobic arms (e.g., FIG. 1) wouldtypically be used in non-aqueous base fluids, and star macromoleculeswith mainly hydrophilic arms (e.g., FIG. 2) would typically be used inaqueous base fluids. Without limiting this disclosure to any particulartheory or mechanism, when dispersed in the base fluids, the hydrophilic(FIG. 1, for non-aqueous based fluids) or hydrophobic (FIG. 2, foraqueous-based fluids) interaction between the arms may help the starmacromolecules to form a transient network, which can increase low shearviscosity and/or suspension capability and reduce fluid loss into theformation. In either embodiment, the arms of the star macromolecule maybe further tailored based on the characteristics of the treatment fluid.

Examples of hydrophobic monomers that may be used in the arms or thecore according to the teachings of the present disclosure include, butare not limited to, styrene, substituted styrene, alkenes (such asethylene, propylene), alkyl acrylate, alkyl methacrylate, acrylonitrile,methacrylonitrile, N-alkyl acrylamide and N-alkyl methacrylamide inwhich the alkyl groups contain more than 3 hydrocarbon chains, vinylacetate, vinyl esters, N-vinylamides, isoprene, butadiene, diesters ofmaleic, fumaric, or itaconic acid, and any combination or derivativethereof.

Examples of hydrophilic monomers that may be used in the arms or thecore according to the teachings of the present disclosure includeanionic, cationic, amphoteric, and nonionic monomers. Anionic monomersthat may be suitable in certain embodiments of the present disclosureinclude, but are not limited to acrylic acid, methacrylic acid, maleicacid, fumaric acid, itaconic acid, monoesters of maleic, fumaric, oritaconic acid, sodium vinylsulfonate, sodium allyl or methallylsulfonate, sodium styrenesulfonate, 2-acrylamido-2-methylpropanesulfonicacid (AMPS), sodium 3-allyloxy-2-hydroxypropane-1-sulfonate (AHPS), andvinylphosphonic acid, and any combination or derivative thereof.Although the acids can be polymerized directly, in certain embodimentsthey are neutralized with base from alkali metal hydroxide, alkalineearth metal hydroxide, ammonia, and amines before polymerization.

Cationic monomers generally contain an amine or ammonium group. Examplesof cationic monomers include, but are not limited to, the quaternaryammonium cationic form of 2-, 3- or 4-vinylpyridine, N-vinylimidazole,2-methyl-1-vinylimidazole, N-(3-(dimethylamino)propyl) methacrylamide,2-(diethylamino)ethyl methacrylate,(3-acrylamidopropyl)trimethylammonium chloride, diallyldimethylammoniumchloride, and any combination or derivative thereof. The amine groups inthe cationic monomers can be converted into quaternary ammonium byalkylating agents such as alkyl or aryl halides, or under acidicconditions.

Amphoteric monomers are monomers that contain both anionic and cationicgroups. Examples of amphoteric monomers include, but are not limited to,betaine, sulfobetaine (or sultaine), and phosphobetaine-type monomers,and any combination or derivative thereof.

Examples of nonionic monomers include, but are not limited to,acrylamide, methacrylamide, N-alkyl acrylamides or methacrylamides inwhich the alkyl group contains 1-3 hydrocarbon chains,N-[tris(hydroxymethyl)methyl]acrylamide, N-vinylpyrrolidone,N-vinylcaprolactam, monovinyl or monoallyl ethers of polyols (such asethylene glycol monovinyl ether, ethylene glycol monoallyl ether, andglycerol monoallyl ether), mono-acrylates or methacrylates of poyols(such as 2-hydroxyethyl acrylate and poly(ethylene glycol)monomethacrylate), and N-vinylamides (such as N-vinylformamide andN-vinylacetamide), and any combination or derivative thereof. Note thatthe acrylate- and acrylamide-based monomers can be converted to anionicmonomers after hydrolysis in water, while N-vinylamides can be convertedinto cationic monomers after hydrolysis in water.

The crosslinkers used to form the hydrophilic core can be eitherhydrophobic or hydrophilic. Examples of these crosslinkers include, butare not limited to, divinyl ether, diallyl ether, vinyl or allyl ethersof polyglycols or polyols, divinylbenzene,1,3-divinylimidazolidin-2-one, divinyltetrahydropyrimidin-2(1H)-one,dienes, allyl amines, N-vinyl-3(E)-ethylidene pyrrolidone, ethylidenebis(N-vinylpyrrolidone), acrylates (such as ethylene glycol diacrylate,polyethylene glycol diacrylates, trimethylolpropane triacrylate,pentaerythritol tetraacrylate), methacrylates (such as ethylene glycoldimethacrylate, polyethylene glycol dimethacrylates, trimethylolpropanetrimethacrylate, pentaerythritol tetramethacrylate), diacrylamides (suchas methylene bisacrylamide and ethylene bisacrylamide),dimethacrylamides, vinyl or allyl esters (such as diallylphthalate,allyl acrylate, allyl methacrylate, vinyl acrylate, vinyl methacrylate,N-vinylacrylamide, N-vinylmethacrylamide, N-allylacrylamide, andN-allylmethacrylamide), triallyl-1,3-5-triazine-2,4,6(1H,3H,5H)-trione,2,4,6-triallyloxy-1,3,5-triazine, and any combination of any of theforegoing.

In certain embodiments, the core may swell in the base fluid to provideviscosity control and fluid loss control at the same time. The additionof the hydrophilic and/or hydrophobic segments to the arms can changethe compatibility between the polymer and the base fluid. Theintermolecular self-association of the hydrophilic segments andhydrophilic segments also may induce shear thinning behavior of the starmacromolecule, which may be beneficial to certain treatment fluids. Themolecular weight and compositions of the arm segments may be tailored sothe structure of the star macromolecule is tuned to fit in differentapplications. For example, the viscosity of the treatment fluid may becontrolled by adjusting the compositions of the arms to increase ordecrease the repulsion between the individual star macromolecules.

In certain embodiments, the treatment fluid may further comprise abridging agent to control fluid loss. In some cases, the weighting agentalso works as a bridging agent. In these embodiments, the starmacromolecule and the bridging agent may aggregate to form a filtercake. The filter cake may form a barrier to prevent loss of the basefluid into the surrounding formation.

In certain embodiments, the bridging agent may be present in thetreatment fluid in an amount sufficient for a particular application.For example, the bridging agent may be included in the treatment fluidto provide the desired degree of fluid loss control. In certainembodiments, the bridging agent may be present in the treatment fluid inan amount up to about 200 lb/bbl. In certain embodiments, the bridgingagent may have a particle size in the range of from about 1 micron toabout 200 microns. In certain embodiments, the bridging particle size isin the range of from about 1 to about 100 microns but may vary fromformation to formation. The particle size used may be determined by,among other factors, the pore throat size of the formation.

In accordance with some embodiments of the present disclosure, thebridging agent is preferably self-degrading or degradable in a suitableclean-up solution (e.g., a mutual solvent, water, an acid solution,etc.). When choosing a particular bridging agent to use, one should beaware of the performance of that bridging agent at the temperature rangeof the application. Examples of suitable bridging agents include, butare not necessarily limited to, magnesium citrate, calcium citrate,calcium succinate, calcium maleate, calcium tartrate, magnesiumtartrate, bismuth citrate, calcium carbonate, sodium chloride and othersalts, and the hydrates thereof.

According to certain embodiments, the star macromolecules of the presentdisclosure may be synthesized using an “arm first” method. “Arm first”means that making the polymeric arms with a functional terminal atom orgroup is the first step to make the star structure. With functionalterminal group as macroinitiator or macromonomer, the crosslinked corecan be synthesized with multi-vinyl cross-linkers. If the arm isterminated with atom transfer radical polymerization (ATRP) functionalterminal group and the arm acts as a macroinitiator, the star structurecan be made by crosslinking multi-vinyl crosslinkers with ATRP method.If the arm is terminated with polymerizable double bond (macromonomer),free radical polymerization can be used to make the core and starstructure. In these embodiments, the first formed ATRP macroinitiatorcan be prepared by conducting a sequential ATRP (co)polymerization ofhydrophilic or hydrophobic and hydrophilic monomers or precursorsthereof or can be prepared by other polymerization procedures thatprovide a functional terminal atom or group that can be converted intoan ATRP initiator. Then the macroinitiator can be mixed with multi-vinylcrosslinkers and polymerized in a one-pot procedure.

In certain embodiments, the treatment fluid may further comprise anadditional fluid loss additive. The additional fluid loss additive maybe present in the treatment fluid in an amount sufficient for aparticular application. For example, the additional fluid loss additivemay be included in the treatment fluid in an amount of about 0.1 poundsper barrel to about 50 pounds per barrel. A person of skill in the art,with the benefit of this disclosure, would know how much additionalfluid loss additive to include in the treatment fluid to accomplish adesired goal, depending on, for example, the permeability of thesubterranean formation.

In certain embodiments, the treatment fluid may further comprise anadditional viscosifying agent or thinner. By way of example, aviscosifying agent may be used in a treatment fluid to impart asufficient carrying capacity and/or thixotropy to the treatment fluid.For example, where the treatment fluid is a drilling fluid, theviscosifying agent enables the drilling fluid to transport drillcuttings and/or weighting materials, prevent the undesired settling ofthe drilling cuttings and/or weighting materials.

Where present, a variety of different viscosifying agents may be usedthat are suitable for use in a treatment fluid. Examples of suitableviscosifiers include, inter alia, biopolymers (e.g., xanthan andsuccinoglycan), cellulose, cellulose derivatives (e.g.,hydroxyethylcellulose), guar, guar derivatives (e.g., hydroxypropylguar), and any combination or derivative thereof. In certain embodimentsof the present invention, the viscosifier is guar. Commerciallyavailable examples of suitable viscosifiers include, but are not limitedto, those that are available from Halliburton Energy Services, Inc.,under the trade name N-VIS®. Combinations of viscosifying agents mayalso be suitable. The particular viscosifying agent used depends on anumber of factors, including the viscosity desired, chemicalcompatibility with other fluids used in formation of the wellbore, andother wellbore design concerns.

The treatment fluid according to the present disclosure may furthercomprise additional additives as deemed appropriate by one of ordinaryskill in the art, with the benefit of this disclosure. Examples of suchadditives include, but are not limited to, emulsifiers, wetting agents,dispersing agents, shale inhibitors, pH-control agents,filtration-control agents, alkalinity sources such as lime and calciumhydroxide, salts, or combinations thereof.

The present disclosure in some embodiments provides methods for usingthe treatment fluids to carry out a variety of subterranean treatments,including but not limited to, hydraulic fracturing treatments, acidizingtreatments, and drilling operations. In some embodiments, the treatmentfluids of the present disclosure may be used in treating a portion of asubterranean formation, for example, in acidizing treatments such asmatrix acidizing or fracture acidizing. In certain embodiments, atreatment fluid may be introduced into a subterranean formation. In someembodiments, the treatment fluid may be introduced into a well bore thatpenetrates a subterranean formation. In some embodiments, the treatmentfluid may be introduced at a pressure sufficient to create or enhanceone or more fractures within the subterranean formation (e.g., hydraulicfracturing).

As the treatment fluid is circulated through the wellbore, the starmacromolecule may prevent the base fluid from being lost to theformation pores or fractures. Without being limited by theory, it isbelieved that the swollen star macromolecule itself can block some poresof the formation and also may form at least a portion of a filter cakealong with a bridging agent on the surface of the formation to preventfurther fluid loss to the formation. This can, among other benefits,reduce the fluid loss and prevent lost circulation while the wellbore isbeing drilled and/or during subsequent treatments in the wellbore.

In accordance with embodiments of the present invention, a treatmentfluid that comprises a base fluid and a star macromolecule may be usedas a drilling fluid in drilling a wellbore. In certain embodiments, adrill bit may be mounted on the end of a drill string that may compriseseveral sections of drill pipe. The drill bit may be used to extend thewellbore, for example, by the application of force and torque to thedrill bit. A drilling fluid may be circulated downwardly through thedrill pipe, through the drill bit, and upwardly through the annulusbetween the drill pipe and wellbore to the surface. In an embodiment,the drilling fluid may be employed for general drilling of wellbore insubterranean formations, for example, through non-producing zones. Inanother embodiment, the drilling fluid may be designed for drillingthrough hydrocarbon-bearing zones.

The treatment fluids and/or other compositions disclosed herein maydirectly or indirectly affect one or more components or pieces ofequipment associated with the preparation, delivery, recapture,recycling, reuse, and/or disposal of the disclosed treatment fluid. Forexample, and with reference to FIG. 3, the disclosed treatment fluid maydirectly or indirectly affect one or more components or pieces ofequipment associated with an exemplary wellbore drilling assembly 100,according to one or more embodiments. It should be noted that while FIG.3 generally depicts a land-based drilling assembly, those skilled in theart will readily recognize that the principles described herein areequally applicable to subsea drilling operations that employ floating orsea-based platforms and rigs, without departing from the scope of thedisclosure.

As illustrated, the drilling assembly 100 may include a drillingplatform 102 that supports a derrick 104 having a traveling block 106for raising and lowering a drill string 108. The drill string 108 mayinclude, but is not limited to, drill pipe and coiled tubing, asgenerally known to those skilled in the art. A kelly 110 supports thedrill string 108 as it is lowered through a rotary table 112. A drillbit 114 is attached to the distal end of the drill string 108 and isdriven either by a downhole motor and/or via rotation of the drillstring 108 from the well surface. As the bit 114 rotates, it creates aborehole 116 that penetrates various subterranean formations 118.

A pump 120 (e.g., a mud pump) circulates drilling fluid 122 through afeed pipe 124 and to the kelly 110, which conveys the drilling fluid 122downhole through the interior of the drill string 108 and through one ormore orifices in the drill bit 114. The drilling fluid 122 is thencirculated back to the surface via an annulus 126 defined between thedrill string 108 and the walls of the borehole 116. At the surface, therecirculated or spent drilling fluid 122 exits the annulus 126 and maybe conveyed to one or more fluid processing unit(s) 128 via aninterconnecting flow line 130. After passing through the fluidprocessing unit(s) 128, a “cleaned” drilling fluid 122 is deposited intoa nearby retention pit 132 (i.e., a mud pit). While illustrated as beingarranged at the outlet of the wellbore 116 via the annulus 126, thoseskilled in the art will readily appreciate that the fluid processingunit(s) 128 may be arranged at any other location in the drillingassembly 100 to facilitate its proper function, without departing fromthe scope of the scope of the disclosure.

One or more of the disclosed star macromolecules may be added to thedrilling fluid 122 via a mixing hopper 134 communicably coupled to orotherwise in fluid communication with the retention pit 132. The mixinghopper 134 may include, but is not limited to, mixers and related mixingequipment known to those skilled in the art. In other embodiments,however, the disclosed star macromolecules may be added to the drillingfluid 122 at any other location in the drilling assembly 100. In atleast one embodiment, for example, there could be more than oneretention pit 132, such as multiple retention pits 132 in series.Moreover, the retention put 132 may be representative of one or morefluid storage facilities and/or units where the disclosed starmacromolecule may be stored, reconditioned, and/or regulated until addedto the drilling fluid 122.

As mentioned above, the disclosed treatment fluids and/or othercompositions may directly or indirectly affect the components andequipment of the drilling assembly 100. For example, the disclosedtreatment fluids and/or other compositions may directly or indirectlyaffect the fluid processing unit(s) 128 which may include, but is notlimited to, one or more of a shaker (e.g., shale shaker), a centrifuge,a hydrocyclone, a separator (including magnetic and electricalseparators), a desilter, a desander, a separator, a filter (e.g.,diatomaceous earth filters), a heat exchanger, or any fluid reclamationequipment. The fluid processing unit(s) 128 may further include one ormore sensors, gauges, pumps, compressors, and the like used store,monitor, regulate, and/or recondition the exemplary treatment fluid.

The disclosed treatment fluids and/or other compositions may directly orindirectly affect the pump 120, which representatively includes anyconduits, pipelines, trucks, tubulars, and/or pipes used to fluidicallyconvey the treatment fluid downhole, any pumps, compressors, or motors(e.g., topside or downhole) used to drive the treatment fluid intomotion, any valves or related joints used to regulate the pressure orflow rate of the treatment fluid, and any sensors (i.e., pressure,temperature, flow rate, etc.), gauges, and/or combinations thereof, andthe like. The disclosed treatment fluid may also directly or indirectlyaffect the mixing hopper 134 and the retention pit 132 and theirassorted variations.

The disclosed treatment fluids and/or other compositions may alsodirectly or indirectly affect the various downhole equipment and toolsthat may come into contact with the treatment fluid such as, but notlimited to, the drill string 108, any floats, drill collars, mud motors,downhole motors and/or pumps associated with the drill string 108, andany MWD/LWD tools and related telemetry equipment, sensors ordistributed sensors associated with the drill string 108. The disclosedtreatment fluid may also directly or indirectly affect any downhole heatexchangers, valves and corresponding actuation devices, tool seals,packers and other wellbore isolation devices or components, and the likeassociated with the wellbore 116. The disclosed treatment fluid may alsodirectly or indirectly affect the drill bit 114, which may include, butis not limited to, roller cone bits, PDC bits, natural diamond bits, anyhole openers, reamers, coring bits, etc.

While not specifically illustrated herein, the disclosed treatmentfluids and/or other compositions may also directly or indirectly affectany transport or delivery equipment used to convey the treatment fluidto the drilling assembly 100 such as, for example, any transportvessels, conduits, pipelines, trucks, tubulars, and/or pipes used tomove the treatment fluid from one location to another, any pumps,compressors, or motors used to drive the treatment fluid into motion,any valves or related joints used to regulate the pressure or flow rateof the treatment fluid, and any sensors (i.e., pressure andtemperature), gauges, and/or combinations thereof, and the like.

An embodiment of the present disclosure is a method comprising:providing a treatment fluid that comprises: an aqueous base fluid; and astar macromolecule that comprises: a hydrophilic polymeric core, a firstgroup of polymeric arms attached to the core wherein each of the arms inthe first group consists of hydrophilic monomers, and a second group ofpolymeric arms attached to the core wherein each of the arms in thesecond group comprises at least one hydrophilic homopolymeric segmentand at least one hydrophobic homopolymeric segment; and introducing thetreatment fluid into a wellbore penetrating at least a portion of asubterranean formation. Optionally, the treatment fluid is a drillingfluid. Optionally, the treatment fluid further comprises a bridgingagent. Optionally, the star macromolecule comprises at least fivepolymeric arms. Optionally, the first group contains more polymeric armsthan the second group. Optionally, each polymeric arm in the secondgroup consists of a single hydrophilic homopolymeric segment attached tothe core and a single hydrophobic homopolymeric segment at a distal endof the arm. Optionally, the treatment fluid is introduced into thewellbore using at least one pump.

Another embodiment of the present disclosure is a method comprising:providing a treatment fluid that comprises: a non-aqueous base fluid;and a star macromolecule that comprises: a polymeric core, a first groupof polymeric arms attached to the core wherein each of the arms in thefirst group consists of hydrophobic monomers, and a second group ofpolymeric arms attached to the core wherein each of the arms in thesecond group comprises at least one hydrophobic homopolymeric segmentand at least one hydrophilic homopolymeric segment; and introducing thetreatment fluid into a wellbore penetrating at least a portion of asubterranean formation. Optionally, the treatment fluid is a drillingfluid. Optionally, the treatment fluid further comprises a bridgingagent. Optionally, the star macromolecule comprises at least fivepolymeric arms. Optionally, the first group contains more polymeric armsthan the second group. Optionally, each polymeric arm in the secondgroup consists of a single hydrophobic homopolymeric segment attached tothe core and a single hydrophilic homopolymeric segment at the distalend of the arm. Optionally, the polymeric core is hydrophobic.

Another embodiment of the present disclosure is a compositioncomprising: a base fluid; a star macromolecule that comprises apolymeric core and a plurality of at least five polymeric arms attachedto the core, wherein at least one of the polymeric arms comprises atleast one hydrophilic homopolymeric segment and at least one hydrophobichomopolymeric segment; and a bridging agent. Optionally, the base fluidcomprises an aqueous fluid and the polymeric core is hydrophilic.Optionally, the base fluid comprises a non-aqueous fluid and thepolymeric core is hydrophobic. Optionally, at least one of the polymericarms consists of hydrophilic monomers. Optionally, at least one of thepolymeric arms consists of hydrophobic monomers. Optionally, thepolymeric core comprises monovinyl monomers.

Therefore, the present disclosure is well adapted to attain the ends andadvantages mentioned as well as those that are inherent therein. Theparticular embodiments disclosed above are illustrative only, as thepresent disclosure may be modified and practiced in different butequivalent manners apparent to those skilled in the art having thebenefit of the teachings herein. While numerous changes may be made bythose skilled in the art, such changes are encompassed within the spiritof the subject matter defined by the appended claims. Furthermore, nolimitations are intended to the details of construction or design hereinshown, other than as described in the claims below. It is thereforeevident that the particular illustrative embodiments disclosed above maybe altered or modified and all such variations are considered within thescope and spirit of the present disclosure. In particular, every rangeof values (e.g., “from about a to about b,” or, equivalently, “fromapproximately a to b,” or, equivalently, “from approximately a-b”)disclosed herein is to be understood as referring to the power set (theset of all subsets) of the respective range of values. The terms in theclaims have their plain, ordinary meaning unless otherwise explicitlyand clearly defined by the patentee.

What is claimed is:
 1. A method comprising: providing a treatment fluidthat comprises: a non-aqueous base fluid; and a star macromolecule thatcomprises: a polymeric core comprising styrene-methyl acrylatebutadiene, a first group of polymeric arms attached to the core whereineach of the arms in the first group consists of hydrophobic monomers,and a second group of polymeric arms attached to the core wherein eachof the arms in the second group comprises at least one hydrophobichomopolymeric segment and at least one hydrophilic homopolymericsegment; and introducing the treatment fluid into a wellbore penetratingat least a portion of a subterranean formation.
 2. The method of claim 1wherein the treatment fluid is a drilling fluid.
 3. The method of claim1 wherein the treatment fluid further comprises a bridging agent.
 4. Themethod of claim 1 wherein the star macromolecule comprises at least fivepolymeric arms.
 5. The method of claim 1 wherein the first groupcontains more polymeric arms than the second group.
 6. The method ofclaim 1 wherein each polymeric arm in the second group consists of asingle hydrophobic homopolymeric segment attached to the core and asingle hydrophilic homopolymeric segment at the distal end of the arm.7. The method of claim 1 wherein the polymeric core is hydrophobic.